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The Bayu-Undan field lies in the Timor Sea, 500km offshore of north-west Darwin.
The Bayu-Undan field lies in the Timor Sea, 500km offshore of north-west Darwin.
Testing the Semisubmersible Eagle, on the Undan field.
Testing the Semisubmersible Eagle, on the Undan field.
 Artist's impression of the Bayu-Undan upstream development concept.
Artist's impression of the Bayu-Undan upstream development concept.
Schematic of the contract strategy for the Bayu-Undan field.
Schematic of the contract strategy for the Bayu-Undan field.
 The development plans graph. Field development commenced in 1999 and is expected to lead to the first production of condensate and LPG in 2001.
The development plans graph. Field development commenced in 1999 and is expected to lead to the first production of condensate and LPG in 2001.
 The FPSO, showing the single-point mooring.
The FPSO, showing the single-point mooring.
The Buffalo Venture FPSO.
The Buffalo Venture FPSO.
 The wellhead platform.
The wellhead platform.
 Process equipment on the Buffalo Venture.
Process equipment on the Buffalo Venture.
Adding buoyancy modules during the riser installation.
Adding buoyancy modules during the riser installation.
 Installation of the wellhead platform by the Ron Tappmeyer.
Installation of the wellhead platform by the Ron Tappmeyer.
 Towing the wellhead platform to the Big Bank.
Towing the wellhead platform to the Big Bank.
The FPSO, showing single-point mooring and swivel.
The FPSO, showing single-point mooring and swivel.
 The Northern Carnarvon basin, showing WA-267-P.
The Northern Carnarvon basin, showing WA-267-P.
 Artists impression of the Gorgon development, showing the main platform and subsea facilities.
Artists impression of the Gorgon development, showing the main platform and subsea facilities.
Schematic of the Gorgon development.
Schematic of the Gorgon development.
 Artists impression of the Gorgon development, showing the main platform and subsea facilities.
Artists impression of the Gorgon development, showing the main platform and subsea facilities.
 Aerial view of the Marine 5000, used to implement the AU$300 million drilling programme.
Aerial view of the Marine 5000, used to implement the AU$300 million drilling programme.
A side view of the Marine 5000.
A side view of the Marine 5000.
 Lifting the pre-assembled units (PAUs) onto the Northern Endeavour at the Sembawang shipyard, in Singapore.
Lifting the pre-assembled units (PAUs) onto the Northern Endeavour at the Sembawang shipyard, in Singapore.
 Fabrication of the PAUs at United Construction, Freemantle.
Fabrication of the PAUs at United Construction, Freemantle.
Lower turret at Noell Abu Dhabi, UAE.
Lower turret at Noell Abu Dhabi, UAE.
 Lifting the turret gantry structure onto the Northern Endeavour at Sembawang.
Lifting the turret gantry structure onto the Northern Endeavour at Sembawang.
 FPSO mooring piles.
FPSO mooring piles.
Northern Endeavour en route to the Timor Sea. Clearly visible is the debutaniser column, behind the forward internal turret.
Northern Endeavour en route to the Timor Sea. Clearly visible is the debutaniser column, behind the forward internal turret.
 Liuhua 11-1 field top carbonate depth structure map.
Liuhua 11-1 field top carbonate depth structure map.
 Computer-generated schematic of Liuhua 11-1 FPS and FPSO.
Computer-generated schematic of Liuhua 11-1 FPS and FPSO.
The FPS is a modified semi-submersible drilling rig. Shown are the 25 flexible catenary lines on the FPS riser system.
The FPS is a modified semi-submersible drilling rig. Shown are the 25 flexible catenary lines on the FPS riser system.
 FPS Nanhai Tiao Zhan was converted from a semi-submersible drilling rig, purchased in September 1993.
FPS Nanhai Tiao Zhan was converted from a semi-submersible drilling rig, purchased in September 1993.
 FPSO Nanhai Sheng Li. The FPSO supports the processing equipment necessary to handle up to 5,000bbl of oil and 300,000bbl of total fluids per day.
FPSO Nanhai Sheng Li. The FPSO supports the processing equipment necessary to handle up to 5,000bbl of oil and 300,000bbl of total fluids per day.
The shuttle tanker Navion Munin, on location at the Lufeng field.
The shuttle tanker Navion Munin, on location at the Lufeng field.
 The Navion Munin cargo tank section consists of 18 cargo tanks and two slop tanks, giving a total capacity of 101,400m<SUP>3</SUP>.
The Navion Munin cargo tank section consists of 18 cargo tanks and two slop tanks, giving a total capacity of 101,400m3.
 Navion Munin is moored using the submerged turret system originally designed for shuttle-tanker loading.
Navion Munin is moored using the submerged turret system originally designed for shuttle-tanker loading.
Production on-board Navion Munin is designed to process a wide range of oil and water rates.
Production on-board Navion Munin is designed to process a wide range of oil and water rates.
 Schematic of the FPSO over the Lufeng field.
Schematic of the FPSO over the Lufeng field.
 Schematic of the anchoring system, employed to moor the Navion Munin.
Schematic of the anchoring system, employed to moor the Navion Munin.
Schematic of the subsea completion on Lufeng.
Schematic of the subsea completion on Lufeng.
 The Malampaya field development diagram.
The Malampaya field development diagram.
 Schematic of the Malmpaya complex.
Schematic of the Malmpaya complex.
The mating of the integrated topside facilities and the gravity base structure of the Malampaya platform.
The mating of the integrated topside facilities and the gravity base structure of the Malampaya platform.
 To ensure an even surface, 361 mounds of rock were placed, totalling 17,000t.
To ensure an even surface, 361 mounds of rock were placed, totalling 17,000t.
 A channel 150m wide and 12m deep was dredged from Green Beach to Subic Bay.
A channel 150m wide and 12m deep was dredged from Green Beach to Subic Bay.
The concrete gravity structure is permanently ballasted by placing 75,000t of iron ore in its open cells.
The concrete gravity structure is permanently ballasted by placing 75,000t of iron ore in its open cells.
 Rock dumping enables scour protection of the gravity structure.
Rock dumping enables scour protection of the gravity structure.
 The $64 million EPIC contract for the provision of a platform was won by Bouygues Offshore.
The $64 million EPIC contract for the provision of a platform was won by Bouygues Offshore.
The topsides, in the form of a six-leg jack-up barge, were towed on top of the submerged jacket. Afterwards, the deck legs were lowered.
The topsides, in the form of a six-leg jack-up barge, were towed on top of the submerged jacket. Afterwards, the deck legs were lowered.
 The 1200t six-leg jacket, equipped with temporary catamaran buoyancy.
The 1200t six-leg jacket, equipped with temporary catamaran buoyancy.
 Following the deck installation, the risers, boat landings and caissons were hooked up.
Following the deck installation, the risers, boat landings and caissons were hooked up.
The Stag A platform was elevated with a 20m air gap.
The Stag A platform was elevated with a 20m air gap.
 The topsides and jacket, ready for sailaway.
The topsides and jacket, ready for sailaway.
 The Wonnich topsides were lowered into position.
The Wonnich topsides were lowered into position.
The transportation barge leaving Freemantle harbour.
The transportation barge leaving Freemantle harbour.
 The lower substructure being loaded out.
The lower substructure being loaded out.
 The installation of the topsides.
The installation of the topsides.
The upper and lower substructure, topsides and piles en route to the site.
The upper and lower substructure, topsides and piles en route to the site.
 Location map of Langsa.
Location map of Langsa.
 The block location map.
The block location map.
The Langsa field covers 77km<sup>2</sup> and is found 90km ENE of Mobil/Exxon’s giant Arun gas/condensate field.
The Langsa field covers 77km2 and is found 90km ENE of Mobil/Exxon’s giant Arun gas/condensate field.
 The PM-3 Commercial Arrangement Area (CAA) project centres on the installation of four new wellhead platforms, a central processing platform, compression annexe platform, floating storage offloading vessel and inter-field pipelines.
The PM-3 Commercial Arrangement Area (CAA) project centres on the installation of four new wellhead platforms, a central processing platform, compression annexe platform, floating storage offloading vessel and inter-field pipelines.
 The topsides were installed in a novel floatover operation using the COSCO Class 2 dynamic positioned (DP) Heavy Lift Vessel (HLV) Tai An Kou.
The topsides were installed in a novel floatover operation using the COSCO Class 2 dynamic positioned (DP) Heavy Lift Vessel (HLV) Tai An Kou.
This was the first floatover performed using DP control and the first such operation for the Tai An Kou.
This was the first floatover performed using DP control and the first such operation for the Tai An Kou.
 Development drilling of the 60-well programme commenced in October 2002.
Development drilling of the 60-well programme commenced in October 2002.
 The PM-3 CAA project will extract oil and gas from six different offshore fields.
The PM-3 CAA project will extract oil and gas from six different offshore fields.
Phase 1 oil production commenced in July 1997. Phases 2 and 3 achieved peak production early 2004.
Phase 1 oil production commenced in July 1997. Phases 2 and 3 achieved peak production early 2004.
 The West Seno field in the Makassar Strait PSC is Indonesia's first deepwater development.
The West Seno field in the Makassar Strait PSC is Indonesia's first deepwater development.
 The first tension leg platform, TLP A, was installed in February 2003.
The first tension leg platform, TLP A, was installed in February 2003.
Development plan of the West Seno field.
Development plan of the West Seno field.
 The floating production unit, located 500m from TLP A, is a spread-moored barge lying in 3,200ft of water.
The floating production unit, located 500m from TLP A, is a spread-moored barge lying in 3,200ft of water.
 The Lorelay pipelay vessel laid the lines out to approx. 1,060m of water at the FPU location.
The Lorelay pipelay vessel laid the lines out to approx. 1,060m of water at the FPU location.
Minerva, Casino Geographe and Thylacine are all located in the Otway Basin, at the southern tip of Australia.
Minerva, Casino Geographe and Thylacine are all located in the Otway Basin, at the southern tip of Australia.
 Minerva came on stream in early 2005. The field is located in VIC/L22 permit, approximately 10km from Port Campbell in 60m of water.
Minerva came on stream in early 2005. The field is located in VIC/L22 permit, approximately 10km from Port Campbell in 60m of water.
 The Minerva development consists of two subsea well completions producing through 10km of 10in pipeline to the shore.
The Minerva development consists of two subsea well completions producing through 10km of 10in pipeline to the shore.
Schematic of the Geographe / Thylacine development.
Schematic of the Geographe / Thylacine development.
 The Mutineer-Exeter oil fields are being developed using the MODEC Venture II FPSO.
The Mutineer-Exeter oil fields are being developed using the MODEC Venture II FPSO.
 The Mutineer-Exeter development is located 150km north of Dampier on the north-west coast of Australia, in the offshore Carnarvon Basin.
The Mutineer-Exeter development is located 150km north of Dampier on the north-west coast of Australia, in the offshore Carnarvon Basin.
MODEC Venture II can be evacuated from the field due to its unique disconnectable turret system.
MODEC Venture II can be evacuated from the field due to its unique disconnectable turret system.
 The FPSO is installed in 156m of water and is capable of processing 100,000bopd.
The FPSO is installed in 156m of water and is capable of processing 100,000bopd.
 The FPSO was converted from the 140,000dwt 1992 Mitsui-built double-hulled Suezmax tanker Fairway.
The FPSO was converted from the 140,000dwt 1992 Mitsui-built double-hulled Suezmax tanker Fairway.
Four wells will be connected to an FPSO as part of the Tui Area Oil Project.
Four wells will be connected to an FPSO as part of the Tui Area Oil Project.
 The drilling operation includes using the Ocean Patriot for drilling up to three exploration wells in the offshore Taranaki basin.
The drilling operation includes using the Ocean Patriot for drilling up to three exploration wells in the offshore Taranaki basin.
 Three oil fields - Tui, Amokura and Pateke reserves located in PEP 38460, the offshore Taranaki basin, New Zealand - are being developed in phases.
Three oil fields - Tui, Amokura and Pateke reserves located in PEP 38460, the offshore Taranaki basin, New Zealand - are being developed in phases.
The FPSO, which has been designed to cater to different types of offtake oil tankers, will handle 120,000 barrels of oil per day.
The FPSO, which has been designed to cater to different types of offtake oil tankers, will handle 120,000 barrels of oil per day.
 The Kikeh Floating Production Storage and Offloading (FPSO) vessel.
The Kikeh Floating Production Storage and Offloading (FPSO) vessel.
 THE FPSO Kikeh has a storage capacity of two million barrels.
THE FPSO Kikeh has a storage capacity of two million barrels.
The Technip spar will incorporate a tender assisted drilling rig to drill and complete the Kikeh wells.
The Technip spar will incorporate a tender assisted drilling rig to drill and complete the Kikeh wells.
 At the bow, is the external turret which can accommodate up to 17 flexible risers.
At the bow, is the external turret which can accommodate up to 17 flexible risers.
 The Kikeh subsea systems are supplied by FMC.
The Kikeh subsea systems are supplied by FMC.
The Rockwater 2 will provide installation support to the Kikeh FSPO.
The Rockwater 2 will provide installation support to the Kikeh FSPO.
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